EP1331366B1 - Kombikraftwerk und Verfahren zu dessen Betrieb - Google Patents

Kombikraftwerk und Verfahren zu dessen Betrieb Download PDF

Info

Publication number
EP1331366B1
EP1331366B1 EP03000550A EP03000550A EP1331366B1 EP 1331366 B1 EP1331366 B1 EP 1331366B1 EP 03000550 A EP03000550 A EP 03000550A EP 03000550 A EP03000550 A EP 03000550A EP 1331366 B1 EP1331366 B1 EP 1331366B1
Authority
EP
European Patent Office
Prior art keywords
exhaust gas
gas turbine
unit
combined plant
supplied
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
Application number
EP03000550A
Other languages
English (en)
French (fr)
Other versions
EP1331366A2 (de
EP1331366A3 (de
Inventor
Hideaki Takasago Res. & Dev. Center Sugishita
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Mitsubishi Heavy Industries Ltd
Original Assignee
Mitsubishi Heavy Industries Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Mitsubishi Heavy Industries Ltd filed Critical Mitsubishi Heavy Industries Ltd
Priority to EP06008776.4A priority Critical patent/EP1867843B1/de
Publication of EP1331366A2 publication Critical patent/EP1331366A2/de
Publication of EP1331366A3 publication Critical patent/EP1331366A3/de
Application granted granted Critical
Publication of EP1331366B1 publication Critical patent/EP1331366B1/de
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
    • F01K23/106—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle with water evaporated or preheated at different pressures in exhaust boiler
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]

Definitions

  • the present invention relates to a gas turbine combined plant, and more particularly to a gas turbine combined plant capable of improving combined efficiency as compared with that of the conventional plant, and a method of operating the same.
  • FIG. 12 is an explanatory diagram showing a conventional gas turbine combined plant.
  • the thermal energy contained in the exhaust gas of a gas turbine 820 is recovered by an HRSG 810 to generate steam, the steam is supplied to a steam turbine 860 connected with a generator 868 to thereby drive the generator 868, and thereby electric power is generated.
  • FIG. 13 is an explanatory diagram showing a conventional regenerative type gas turbine combined plant.
  • This regenerative type gas turbine combined plant has a regenerator 930, to which the exhaust gas of a gas turbine 920 is supplied. The temperature of the combustion air is then increased by heat exchange between the exhaust gas of the gas turbine 920 and the combustion air compressed by a compressor 922. As a result, the temperature of the combustion air at an inlet of a combustor 923 can be increased, and hence the amount of fuel supplied to the gas turbine 920 can be reduced. Therefore, the efficiency of the gas turbine and the efficiency of the combined plant can be increased. In such means, the combined efficiency in the gas turbine combined plant has been improved to the latter half of 50%-60% range, on a lower heat value (LHV) base.
  • LHV lower heat value
  • Fig. 14 is a Q-T diagram showing a relation between a steam temperature and a quantity of heat exchange in the conventional HRSG.
  • the line showing higher temperature expresses changes of exhaust gas, and the line showing lower temperature expresses changes of steam (water).
  • the area indicated by diagonal lines expresses the magnitude of loss of heat exchange, and as this area increases, the loss of heat exchange increases.
  • DE 196 12 921 A1 describes a combined cycle power plant with a gas turbine, a heat recovery boiler with a superheater and an evaporator, as well as an air heater that heats combustion air by exhaust gas from the gas turbine.
  • US 3,422,800 describes a combined gas turbine and waste heat boiler control system, in which the air entering the gas turbine compressor is controllably heated with gas turbine exhaust gases so as to independently control the compressor inlet temperature.
  • the gas turbine combined plant comprises a gas turbine, an exhaust heat recovery unit that recovers thermal energy contained in the exhaust gas of the gas turbine in a heat recovery stage having at least a superheating unit and an evaporation unit, and an air heating unit that heats combustion air of the gas turbine by the exhaust gas.
  • the plant also comprises an exhaust gas branch line that has a branch portion for branching the exhaust gas and supplies the exhaust gas to the exhaust heat recovery unit and the air heating unit, and an exhaust gas supply line that supplies the exhaust gas after heating the combustion air of the gas turbine in the air heating unit, to between the superheating unit and the evaporation unit.
  • the gas turbine combined plant comprises a gas turbine, an exhaust heat recovery unit that recovers thermal energy contained in the exhaust gas of the gas turbine by providing a plurality of heat recovery stages respectively having at least a superheating unit and an evaporation unit, and air heating units in a plurality of stages that heat combustion air of the gas turbine by the exhaust gas.
  • the plant also comprises an exhaust gas branch line that has a branch portion for branching the exhaust gas and supplies the exhaust gas to the exhaust heat recovery unit and the air heating units in the plurality of stages, a first-stage exhaust gas supply line that supplies the exhaust gas after heating the combustion air of the gas turbine in a first-stage air heating unit to between the superheating unit and the evaporation unit provided in a first heat recovery stage, and a subsequent-stage exhaust gas supply line that supplies the exhaust gas after heating the combustion air of the gas turbine in the air heating unit(s) in and after a second stage, to between the superheating unit and the evaporation unit provided in the heat recovery stage(s) in and after a second stage.
  • the method of operating a gas turbine combined plant which does not form a part of the invention comprises reducing a flow rate of exhaust gas supplied to an air heating unit as a temperature of the exhaust gas increases, at the time of operating the gas turbine combined plant including a gas turbine, an exhaust heat recovery unit that recovers thermal energy from the exhaust gas of the gas turbine, and the air heating unit that heats combustion air of the gas turbine by a part of the exhaust gas of the gas turbine.
  • the method of operating a gas turbine combined plant which does not form a part of this invention comprises reducing a flow rate of exhaust gas supplied to an air heating unit as a load of the gas turbine combined plant increases, at the time of operating the gas turbine combined plant including a gas turbine, an exhaust heat recovery unit that recovers thermal energy from the exhaust gas of the gas turbine, and the air heating unit that heats combustion air of the gas turbine by a part of the exhaust gas of the gas turbine.
  • Fig. 1A and Fig. 1B are explanatory diagrams each showing a gas turbine combined plant.
  • the exhaust gas of a gas turbine 20 to be supplied to an HRSG 10 as an exhaust heat recovery unit is branched, and one of the branched exhaust gas is heat-exchanged with the combustion air of the gas turbine 20 in a regenerator 30 being an air heating unit.
  • the exhaust gas after heat exchange is supplied to between a high-pressure superheater 40 being the superheating unit and a high-pressure evaporator 50 being the evaporation unit, each of which is provided in the HRSG 10.
  • the other branched exhaust gas is supplied to an inlet of the high-pressure superheater 40 in the HRSG 10.
  • the gas turbine combined plant 100 is provided with the HRSG 10, the gas turbine 20, and a high-pressure steam turbine 60.
  • the HRSG 10 is provided with the high-pressure superheater 40 being the superheating unit, and the high-pressure evaporator 50 being the evaporation unit, thereby constituting a heat recovery stage that recovers thermal energy contained in the exhaust gas of the gas turbine 20.
  • the heat recovery stage may be configured by adding a high-pressure economizer 18.
  • feed water to be supplied to the high-pressure evaporator 50 can be warmed by the high-pressure economizer 18, and therefore the high-pressure evaporator 50 can produce steam more efficiently.
  • thermal energy of the exhaust gas can be recovered more effectively by the high-pressure economizer 18, and hence the efficiency of the HRSG 10 can be increased, which is preferable.
  • a piping 70 that is an exhaust gas branch line for guiding the exhaust gas after having driven the gas turbine 20 to the HRSG 10.
  • This piping 70 is branched at a branch portion 78 provided on the upstream side of the HRSG 10, with one being connected to the HRSG 10 and the other being connected to the regenerator 30.
  • the exhaust gas of the gas turbine 20 is supplied to the high-pressure superheater 40 provided in the HRSG 10 and the regenerator 30.
  • the exhaust gas supplied to the high-pressure superheater 40 superheats the saturated steam produced by the high-pressure evaporator 50, to thereby produce superheated steam to be supplied to the high-pressure steam turbine 60.
  • the exhaust gas supplied to the regenerator 30 is heat-exchanged with high-temperature and high-pressure combustion air generated by a compressor 22 in the gas turbine 20 to heat the combustion air.
  • the exhaust gas after having been heat-exchanged in the regenerator 30 is supplied to between the high-pressure superheater 40 and the high-pressure evaporator 50, which are provided in the HRSG 10, passing through a piping 80 that is an exhaust gas supply line being a connection between the regenerator 30 and the HRSG 10.
  • This exhaust gas is supplied to an inlet of the high-pressure superheater 40 and united with the exhaust gas that has superheated the steam, and then fed to the high-pressure evaporator to evaporate water, of which temperature is raised by the high-pressure economizer 18.
  • combustion air having passed through the regenerator 30 may be supplied to between an upstream high-pressure superheater 40a and a downstream high-pressure superheater 40b.
  • the internal cross section of a piping 70a that supplies exhaust gas to the HRSG 10 is different from that of a piping 70b that supplies exhaust gas to the regenerator 30. This is because higher combined efficiency is obtained by supplying a proper amount of exhaust gas to the HRSG 10 and the regenerator 30.
  • the amount of exhaust gas to be supplied to the HRSG 10 and the like varies according to the size of the plant and the load at the time of operation. Therefore, though not clear from Fig. 1A, in the gas turbine combined plant 100, the internal cross section of the piping 70a and the like is adjusted so as to obtain the highest combined efficiency at the time of rated load.
  • a variable restrictor or the like may be provided in the piping 70a and the like to change the internal cross section of the piping 70a and the like according to the load of the gas turbine combined plant 100 or the like.
  • a generator 28 is connected to the gas turbine 20, and the gas turbine 20 is operated to drive the generator 28, to thereby generate electric power.
  • the exhaust gas of the gas turbine 20 is guided to the HRSG 10, and the thermal energy is recovered here.
  • the HRSG 10 used in the 1 st embodiment which does not form a part of the invention is a so-called one-stage type HRSG. This invention is, however, applicable to a two-stage type or a three-stage type HRSG having a plurality of heat recovery stages, described later.
  • steam is generated by the thermal energy recovered from the exhaust gas of the gas turbine 20, and this steam is supplied to the high-pressure steam turbine 60, to drive this. Since the high-pressure steam turbine 60 is also connected with a generator 68, the generator 68 is driven by the high-pressure steam turbine 60 to thereby generate electric power.
  • the exhaust gas of the gas turbine 20 is branched and supplied to the HRSG 10 and the regenerator 30.
  • exhaust gas which has passed through the regenerator 30 and whose temperature has been dropped is supplied to the HRSG 910 (see Fig. 13).
  • high-temperature exhaust gas can be supplied to the high-pressure superheater 40 in the HRSG 10.
  • the flow rate of the exhaust gas to be supplied to the high-pressure superheater 40 can be reduced. Thereby, a heat exchange loss can be reduced as compared with that of the conventional gas turbine combined plant in which all exhaust gas is supplied to a high-pressure superheater 940 (see Fig. 13).
  • the exhaust gas having passed through the regenerator 30 loses thermal energy in the process of heating the combustion air, and the temperature thereof drops. Since the exhaust gas whose temperature has been dropped is supplied to the high-pressure evaporator 50, the temperature of exhaust gas at the inlet of the high-pressure evaporator 50 in the HRSG 10 can be decreased than that of the conventional gas turbine combined plant. By this action, a temperature difference between the inlet temperature and the outlet temperature in the high evaporator 50 can be made smaller than that of the conventional gas turbine combined plant. Thereby, a heat exchange loss in the high-pressure evaporator 50 can be reduced. Further, since the regenerator 30 is provided, the combustion air compressed by the compressor 22 is supplied with the heat of the exhaust gas in the regenerator 30 to thereby raise the temperature of the combustion air, and hence the efficiency of the gas turbine 20 is improved.
  • Fig. 2 is a Q-T diagram showing the gas turbine combined plant according to the first embodiment, which does not form a part of the invention, and a conventional gas turbine combined plant.
  • a solid line in the figure shows the plant according to the first embodiment, and a dotted line in the figure shows the plant according to the conventional gas turbine combined plant.
  • the line showing higher temperature of the lines indicates changes of the exhaust gas, and the line showing lower temperature indicates changes of the steam (water).
  • the area indicated by the diagonal lines in the figure expresses a magnitude of a loss of the heat exchange, and as this area increases, the loss of the heat exchange increases.
  • the exhaust gas of the gas turbine 20 is branched, and one of the branched exhaust gases is directly supplied to the high-pressure superheater 40 in the HRSG 10. Therefore, as shown in Fig. 2, the inlet temperature T sh-hpi of the high-pressure superheater can be increased as compared with the conventional gas turbine combined plant.
  • the steam temperature T sh-hpi to be supplied to the high-pressure steam turbine 60 can be increased as compared with the conventional gas turbine combined plant, and therefore the efficiency of the high-pressure steam turbine 60 can be improved as compared with the conventional art.
  • the exhaust gas since the exhaust gas is branched, the amount of exhaust gas to be supplied to the high-pressure superheater 40 can be reduced as compared with the conventional art, the heat exchange loss can be reduced also by this action.
  • One of the branched exhaust gases of the gas turbine is supplied to the regenerator 30 (see Fig. 1A), where the temperature of the combustion air is raised and then supplied to between the high-pressure superheater 40 and the high-pressure evaporator 50.
  • the inlet temperature T EV-hpi of the high-pressure evaporator can be dropped as compared with the conventional gas turbine combined plant, and hence a temperature difference between the inlet temperature T EV-hpi and the outlet temperature T EV-hpo in the high-pressure evaporator 50 can be made smaller as compared with the conventional gas turbine combined plant.
  • the quantity of heat exchange in the high-pressure evaporator 50 can be increased than before.
  • the area indicated by the diagonal lines becomes smaller than in the conventional gas turbine combined plant, and hence a heat exchange loss in the HRSG 10 according to this invention can be reduced as compared with the conventional HRSGs 810 and 910 (see Fig. 12 and Fig. 13).
  • Fig. 3 is an explanatory diagram showing the relation between the combined efficiency and the output of the gas turbine combined plant.
  • the solid line in the figure shows the gas turbine combined plant according to this invention, and the dotted line shows the conventional gas turbine combined plant.
  • the combined efficiency of the gas turbine combined plant 100 shows a higher combined efficiency than that of the conventional gas turbine combined plants 800 and 900 (see Fig. 12 and Fig. 13) over the whole output region.
  • the degree of the efficiency is improved by about 1% in the absolute value, as compared with the conventional gas turbine combined plant 800 and the like. Thereby, the fuel cost of the gas turbine combined plant 100 can be reduced. Further, discharge of NO x and CO 2 can be suppressed by the improvement in the combined efficiency.
  • the combined efficiency has been improved from 58% to 59% on the LHV base.
  • the fuel cost can be suppressed by about 500 million Yen per year. Further, the discharge of NO x and CO 2 is reduced at the rate of about 1.7%.
  • Fig. 4A and Fig. 4B are explanatory diagrams each showing a gas turbine combined plant according to a second embodiment of this invention.
  • the gas turbine combined plant 101 has substantially the same configuration as that of the gas turbine combined plant 100 (see Fig. 1A) according to the first embodiment.
  • the plant 101 is different in that a plurality of heat recovery stages each having at least a superheating unit and an evaporation unit is provided in an HRSG 11, being the exhaust heat recovery unit.
  • the rest of the configuration is the same as that of the first embodiment, and therefore the explanation thereof is omitted and the same component is denoted by the same reference symbol.
  • Fig. 4A shows an example of using the three-stage type HRSG 11 having three heat recovery stages
  • Fig. 4B shows an example (only the HRSG 12) of using the two-stage type HRSG 12 having two heat recovery stages.
  • the HRSG 11 comprises a high-pressure heat recovery stage having a high-pressure superheater 40 as the superheating unit, a high-pressure evaporator 50 as the evaporation unit, and a high-pressure economizer 18a.
  • the HRSG 11 also comprises an intermediate-pressure heat recovery stage having an intermediate-pressure superheater 41 and a low-pressure superheater 42 as the superheating units, an intermediate-pressure evaporator 51 as the evaporation unit, and an intermediate-pressure economizer 18b.
  • the HRSG 11 further comprises a low-pressure heat recovery stage having a low-pressure evaporator 52 as the evaporation unit, and a low-pressure economizer 18c (see Fig. 4A).
  • the two-stage type HRSG 12 comprises a high-pressure heat recovery stage having a high-pressure superheater 40 as the superheating unit, a high-pressure evaporator 50 as the evaporation unit, and a high-pressure economizer 18a.
  • the two-stage type HRSG 12 also comprises an intermediate-pressure heat recovery stage having an intermediate-pressure superheater 41 as the superheating unit, an intermediate-pressure evaporator 51 as the evaporation unit, and an intermediate-pressure economizer 18b (see Fig. 4B).
  • the exhaust gas of the gas turbine 20 is branched at the branch portion 78 of the piping 70 that is the exhaust gas branch line, and the branched gases are supplied to the HRSG 11 or the like and to the regenerator 30 being the air heating unit, respectively.
  • the regenerator 30 and the HRSG 11 are connected by the piping 80 which is the exhaust gas supply line, so that the exhaust gas having passed through the regenerator 30 is supplied to between the high-pressure superheater 40 and the high-pressure evaporator 50, which are provided in the HRSG 11 or the like.
  • exhaust gas having a higher temperature than in the conventional gas turbine combined plant can be supplied to the high-pressure superheater 40 in the HRSG 11 or the like. Further, the exhaust gas having passed through the regenerator 30 loses thermal energy in the process of heating the combustion air, and the temperature thereof drops. Since the exhaust gas whose temperature has been dropped is supplied to the high-pressure evaporator 50, a difference in temperature between the exhaust gas at the inlet and that at the outlet of the high-pressure evaporator 50 can be made smaller than in the conventional gas turbine combined plant. By these actions, a heat exchange loss between the high-pressure superheater 40 and the high-pressure evaporator 50 can be reduced as compared with a conventional manner.
  • the efficiency of the gas turbine 20 is improved.
  • the combined efficiency in the gas turbine combined plant 101 can be increased as compared with the conventional manner, and hence the fuel cost can be reduced, and the discharge of NO x and CO 2 can be reduced as compared with the conventional gas turbine combined plant.
  • the heat recovery in the gas turbine combined plant 101 is not limited up to the three stages, but if there are too many stages, the configuration of the HRSG 11 becomes complicated. Therefore, two to four stages are preferable.
  • Fig. 5 is an explanatory diagram showing a gas turbine combined plant according to a third embodiment of this invention.
  • the gas turbine combined plant 102 has substantially the same configuration as that of the gas turbine combined plant 101 (see Fig. 4A) according to the second embodiment, but it is different in that the plant 102 is provided with a plurality of regenerators being the air heating units, and that exhaust gas having passed through the respective regenerators is supplied to the heat recovery stage having at least the superheating unit and the evaporation unit that are provided in an HRSG 13 being the exhaust heat recovery unit, according to the temperature condition required by the heat recovery stage.
  • the rest of the configuration is the same as that of the second embodiment, and therefore the explanation thereof is omitted and the same component is denoted by the same reference symbol.
  • the gas turbine combined plant 102 is also applicable to the two-stage type HRSG, like the gas turbine combined plant 101 according to the second embodiment.
  • the gas turbine combined plant 102 is provided with two regenerators as a plurality of air heating units, that is, a first regenerator 31 and a second regenerator 32 being the air heating units.
  • the outlet of the first regenerator 31 and the HRSG 13 are connected by a piping 80a, being a first-stage exhaust gas supply line, so that the exhaust gas discharged from the first regenerator 31 is supplied to between the high-pressure superheater 40 and the high-pressure evaporator 50.
  • the outlet of the second regenerator 32 and the HRSG 13 are connected by a piping 80b, being a subsequent-stage exhaust gas supply line, so that the exhaust gas discharged from the second regenerator 32 is supplied to between the intermediate-pressure superheater 41 and the intermediate-pressure evaporator 51.
  • the exhaust gas of the gas turbine 20 is branched at the branch portion 78 of the piping 70, and then passes through the regenerators in order of the first regenerator 31 and the second regenerator 32.
  • the air compressed by the compressor 22 passes through the regenerators in order of the second regenerator 32 and the first regenerator 31, and is heat-exchanged with the exhaust gas in this process, to thereby raise the temperature thereof.
  • the temperature t ro1 of the exhaust gas discharged from the first regenerator 31 becomes higher than the temperature t ro2 of the exhaust gas discharged from the second regenerator. Therefore, the exhaust gas discharged from the first regenerator 31 is branched at a branch portion 88, and then is made to pass through the piping 80a and supplied to between the high-pressure superheater 40 and the high-pressure evaporator 50. The exhaust gas discharged from the second regenerator 32 is made to pass through the piping 80b and supplied to between the intermediate-pressure superheater 41 and the intermediate-pressure evaporator 51.
  • the intermediate-pressure superheater 41 and the low-pressure superheater 42 are provided upstream of the intermediate-pressure evaporator 51, but as shown in Fig. 5, the exhaust gas discharged from the second regenerator 32 may be supplied to between the low-pressure superheater 42 and the intermediate-pressure evaporator 51. Further, the exhaust gas discharged from the second regenerator 32 may be supplied to between the intermediate-pressure superheater 41 and the low-pressure superheater 42.
  • the exhaust gas having a more adequate temperature can be supplied to each heat recovery stage, and therefore the loss at the time of heat exchange in the HRSG 13 can be reduced. Further, since the regenerator is provided in two stages, the temperature of the air compressed by the compressor 22 can be increased more efficiently. If the temperature of the exhaust gas discharged from the second regenerator 32 is low and the heat exchange loss is rather increased by supplying the exhaust gas to between the intermediate-pressure superheater 41 and the intermediate-pressure evaporator 51, the exhaust gas may be supplied to the inlet of the low-pressure evaporator 52.
  • the number of stages is not limited to two, and the number of stages may be properly changed according to the number of the heat recovery stages equipped in the exhaust heat recovery unit.
  • the exhaust heat recovery unit having three heat recovery stages has been explained, but the number of the heat recovery stages may be more than three.
  • the number of the heat recovery stages is preferably from two to four.
  • the heat exchanging quantity in the first regenerator 31 and the second regenerator 32 may be made variable to thereby always supply exhaust gas having optimum temperature, even if the load of the gas turbine combined plant 102 changes.
  • Fig. 6A to Fig. 6D are explanatory diagrams each showing a unit that changes the heat exchanging quantity in the regenerator.
  • the unit that changes the heat exchanging quantity includes a unit that changes the flow rate of exhaust gas to be supplied to each regenerator.
  • a flow rate adjusting unit for example, as shown in Fig. 6A, a shield 32a that can change the area of the exhaust gas inlet of the second regenerator 32 may be provided at an exhaust gas inlet or outlet of the second regenerator 32.
  • this shield 32a is shifted, to adjust the flow rate of exhaust gas that flows into the second regenerator 32.
  • the flow rate in the first regenerator 31 upstream thereof also changes.
  • the shield 32a may be adjusted so as to increase the flow rate of exhaust gas flowing into the second regenerator 32.
  • the shield 32a may be adjusted so as to decrease the flow rate of exhaust gas flowing into the second regenerator 32.
  • a damper 36 or a three-way valve 37 may be provided between the first regenerator 31 and the second regenerator 32, to constitute the flow rate adjusting unit.
  • a plurality of valves 38a and 38b may be combined instead of the damper 36, to thereby constitute the flow rate adjusting unit.
  • a rotary valve as shown in Fig. 10C may be used.
  • Fig. 7 is an explanatory diagram showing another unit that changes the heat exchanging quantity in the regenerator.
  • a plurality of first regenerators 31 and a plurality of second regenerators 32 are provided to adjust the number of regenerators that supply exhaust gas corresponding to the load, thereby the flow rate of the exhaust gas to be supplied to the regenerators, being the air heating unit, may be adjusted.
  • the number of regenerators that supply the exhaust gas may be reduced.
  • the air from the compressor 22 (see Fig. 5) is supplied to all regenerators 31a to 31e.
  • the heat exchanging quantity in the first regenerator 31 is to be decreased.
  • the exhaust gas is supplied to the regenerators 31a, 31c, and 31e, but is not supplied to the regenerators 31b and 31d.
  • switching units such as valves provided upstream of the individual regenerators 31a to 31e may be used.
  • the air from the compressor 22 (see Fig. 5) is supplied to all the regenerators 31a to 31e.
  • the first regenerator 31 and the second regenerator 32 having such heat exchanging units are provided, and when the load of the gas turbine combined plant 102 (see Fig. 5) changes, the heat exchanging quantity in the first regenerator 31 and the second regenerator 32 is changed corresponding to the load.
  • exhaust gas having an optimum temperature can be supplied to each of the heat recovery stages in the HRSG 13 (see Fig. 5). Therefore, since the heat exchanging quantity in the HRSG 13 can be suppressed to the minimum, it is possible to suppress a drop of the combined efficiency of the gas turbine combined plant 102 due to fluctuations of the load.
  • FIG. 8 is an explanatory diagram showing a gas turbine combined plant according to a fourth embodiment of this invention.
  • This gas turbine combined plant 103 has substantially the same configuration as that of the gas turbine combined plant 100, but it is different in that the plant 103 is provided with a branch flow adjusting unit that adjusts the flow rate of exhaust gas to be supplied to the HRSG 10 as the exhaust heat recovery unit and the regenerator 30 as the air heating unit, at the branch portion 78 (see Fig. 1A) provided in the piping 70 which is the exhaust gas branch line.
  • the rest of the configuration is the same as that of the first embodiment, which does not form a part of the invention and therefore the explanation thereof is omitted and the same component is denoted by the same reference symbol.
  • the gas turbine combined plant 103 includes a damper 75 that is the branch flow adjusting unit provided at the branch portion 78 (see Fig. 1A) of the piping 70 as the exhaust gas branch line that supplies exhaust gas to the HRSG 10 and the regenerator 30 so as to adjust the flow rate of the exhaust gas to be supplied to the HRSG 10 and the regenerator 30.
  • Fig. 9 is an explanatory diagram showing the relation between the combined efficiency and the amount of exhaust gas branched to the regenerator when the load of the plant is changed. As shown in this figure, in the gas turbine combined plant, the combined efficiency changes corresponding to the load, and at the same time, there exists an optimum value for the amount of branch exhaust gas to be supplied to the regenerator 30. Therefore, the flow rate of the exhaust gas to be supplied to the regenerator 30 is adjusted at the time of partial load or at the time of full load, so that operation is possible with the combined efficiency being kept high, even if the load is changed.
  • the branch flow adjusting unit applicable to this invention includes the damper 75.
  • the damper 75 When the damper 75 is used, only opening or closing a switching door 75a can adjust the flow rate of the exhaust gas, allowing the branch flow adjusting unit to have a simple structure, which is preferable.
  • a large amount of exhaust gas is supplied to the HRSG 10 and the like, and therefore the pipings 70, 70a and the like are formed of a duct having an outer size of from 4 m to 5 m. Therefore, it is more preferable to use the damper, because the branch flow adjusting unit can be formed in a simpler manner and with more lightweight, as compared with a case of using a valve structure.
  • Fig. 10A to Fig. 10C are explanatory diagrams each showing another example of the branch flow adjusting unit according to the fourth embodiment.
  • the damper 76 may be formed of a plurality of switching doors 76a.
  • the damper 76 can be formed by combining small switching doors 76a, and therefore the switching doors 76a can be manufactured more easily, particularly when large-sized pipings 70, 70a and the like are used. Since the size of the switching doors 76a is small, the force of the exhaust gas acting on each of the switching doors 76a becomes smaller than that of the switching door.
  • the switching doors 76a can endure the impact of the exhaust gas. Hence, the manufacturing cost of the damper 76 can be reduced. Further, the driving force of the switching doors 76a can be reduced, and therefore the energy for the control can be also decreased.
  • the branch flow adjusting unit may be formed of a three-way valve 77, or as shown in Fig. 6D, a plurality of valves may be combined to form the branch flow adjusting unit. In this case, the structure becomes slightly complicated, but the accuracy of flow rate control can be increased, and hence it is preferable. Further, as shown in Fig. 10C, a rotary valve 79 may be used to form the branch flow adjusting unit.
  • the damper 75 or the like, being the branch flow adjusting unit is provided in the gas turbine combined plant 100 (see Fig. 1A) according to the first embodiment, which does not form a part of the invention, but it is not limited to the first embodiment that the branch flow adjusting unit can be provided.
  • the damper 75 or the like which is the branch flow adjusting unit, can be provided in the gas turbine combined plant 101 or 102 according to the second or third embodiment in a like manner. In this case, the same action and effects as explained above are exhibited (hereinafter the same).
  • the method of operating the gas turbine combined plant 103 having the branch flow adjusting unit will be explained below. Referring to Fig. 8 will help you understand this explanation.
  • the flow rate of exhaust gas to be supplied to the regenerator 30 is increased at a low temperature of the exhaust gas, a decrease of the combined efficiency due to the drop of the exhaust gas temperature can be suppressed.
  • the exhaust gas temperature of the gas turbine 20 is lower than that at the time of rated load. Therefore, by increasing the flow rate of the exhaust gas to be supplied to the regenerator 30, the drop of the combined efficiency can be suppressed.
  • the exhaust gas temperature of the gas turbine 20 is still low, and therefore the flow rate of the exhaust gas to be supplied to the regenerator 30 is increased, by adjusting the opening of the damper 75.
  • the opening of the damper 75 is adjusted to reduce the flow rate of the exhaust gas to be supplied to the regenerator 30.
  • a signal for operating the damper 75 is generated in a processor 91 of a control unit 90, based on the temperature information from a thermometer 26 provided at the exhaust gas outlet 20a of the gas turbine 20.
  • the relation between the exhaust gas temperature and the opening of the damper 75 may be stored in advance in a memory section 92 of the control unit 90, and the opening information in the memory section 92 may be referred to when the processor 91 receives the temperature information from the thermometer 26.
  • the controller 93 When a controller 93 of the control unit 90 receives this signal, the controller 93 transmits a drive signal of an actuator 75b provided in the damper 75 to drive the actuator 75b, to thereby open or close the switching door 75a.
  • the opening of the damper 75 may be controlled by the output information of the generator 28 or the like, that is, the load information of the gas turbine combined plant 103, instead of the temperature information.
  • the control unit 90 can be operated in accordance with the operation schedule programmed in advance.
  • the atmospheric temperature is measured together with the exhaust gas temperature by a thermometer 27, and the opening of the damper 75 may be controlled based on the temperature information of the two. If the atmospheric temperature is also used as the control information, more precise flow rate control of the exhaust gas can be performed as compared with the case such that the exhaust gas temperature is singly used, thereby a drop of the combined efficiency can be further suppressed, which is preferable.
  • the configuration may be such that a table representing the relation between the exhaust gas temperature and the atmospheric temperature and the opening of the damper 75 is stored in advance in the memory section 92 of the control unit 90, and the processor 91 refers to this table to generate a signal for operating the switching door 75a.
  • the processor 91 may be realized by special-purpose hardware, or the processor 91 may be constituted of a memory and a CPU (central processing unit) to serve its function by loading a program (not shown) for realizing the function of the processor into the memory and executing the program.
  • This program may be for realizing a part of the function, and further, the function may be realized by combining the program with a program already stored in a computer system.
  • the input unit stands for input devices such as a keyboard and a mouse.
  • the display unit stands for CRT (Cathode Ray Tube) and a liquid crystal display unit.
  • FIG. 11 is an explanatory diagram showing a gas turbine combined plant according to a fifth embodiment of this invention.
  • This gas turbine combined plant 104 has substantially the same configuration as that of the gas turbine combined plant 100, but it is different in that the plant 104 includes an exhaust gas re-combustion unit that supplies fuel to the exhaust gas to reburn the exhaust gas, provided between the branch portion 78 of the piping 70 and the HRSG 10.
  • the rest of the configuration is the same as that of the first to fourth embodiments, and therefore the explanation thereof is omitted and the same component is denoted by the same reference symbol.
  • the exhaust gas of the gas turbine 20 is branched at the branch portion 78 of the piping 70, and one of the branched exhaust gas is supplied to the high-pressure superheater 40 that is the superheating unit in the HRSG 10, being the exhaust heat recovery unit.
  • a combustion improving device 95 being the exhaust gas re-combustion unit, is provided at the inlet of the HRSG 10, wherein fuel is provided to the high-temperature exhaust gas, to thereby reburn the exhaust gas.
  • the combustion improving device 95 may be provided in the piping 70a that connects the branch portion 78 to the HRSG 10.
  • the exhaust gas of the gas turbine 20 is reburnt by the combustion improving device 95, the exhaust gas whose temperature has been raised can be supplied to the high-pressure superheater 40 in the HRSG 10.
  • the temperature of the high-pressure superheated steam generated by the high-pressure superheater 40 can be raised, and hence the steam temperature at the inlet of the high-pressure steam turbine 60 is also raised. Therefore, the output of the high-pressure steam turbine 60 can be increased, which allows the output of a generator 68 to be also increased.
  • the combustion improving device 95 is provided integrally with the HRSG 10, and therefore it is not necessary to provide the combustion improving device 95 as a separate body. Thus, it is preferable that the piping system can be constructed relatively easily.
  • the combustion improving device 95 may be provided between the gas turbine 20 and the branch portion 78.
  • the exhaust gas whose temperature has been raised can be supplied both to the HRSG 10 and the regenerator 30, being the air heating unit, and hence the output of the gas turbine 20 can be also increased at the same time.
  • the output of the whole gas turbine combined plant 104 can be further increased.
  • the combustion improving device 95 may be provided both in the piping 70a that connects the branch portion 78 and the HRSG 10, and in a piping 70b that connects the branch portion 78 and regenerator 30.
  • the temperature of the exhaust gas to be supplied to the HRSG 10 and the regenerator 30 can be separately raised, thereby enabling control taking the combined efficiency into consideration, which is preferable.
  • the combustion improving device 95 is formed integrally with the HRSG 10 and the regenerator 30, the configuration becomes relatively simple.
  • the piping 70a and 70b can be formed of a material having a relatively low heat-resistance, thereby the installation expenses of the piping 70a and the like can be preferably minimized.
  • the combined efficiency of the gas turbine combined plant 104 when the combustion improving device 95 is operated becomes lower than the case such that the combustion improving device 95 is not operated, but the output of power generation itself of the gas turbine combined plant 104 can be increased. Therefore, when the electric power demand is large, particularly from around noon to three o'clock in the afternoon in the summer time, such operation is possible as to ignore a temporary drop of the combined efficiency and to operate the combustion improving device 95 to deal with the power demand.
  • the combustion improving device 95 is provided in the gas turbine combined plant 100 (see Fig. 1A) according to the first embodiment, which does not form a part of the invention, but the combustion improving device 95 can be provided in any other plants.
  • the combustion improving device 95 can be provided in the gas turbine combined plants 101 to 103 according to the second to fourth embodiments in a like manner. In this case, the similar action and effects can be exhibited as well.
  • the exhaust gas of the gas turbine is branched, and a part of the exhaust gas is supplied to the air heating unit, and the remaining is supplied to the exhaust heat recovery unit.
  • the exhaust gas whose temperature is prevented from its drop can be supplied in an appropriate flow rate, to the superheating unit in the heat recovery stage provided in the exhaust heat recovery unit, and hence a heat exchange loss in the superheating unit is reduced.
  • the part of the branched exhaust gas is allowed to pass through the air heating unit so as to heat the combustion air of the gas turbine. As a result, the efficiency of the gas turbine can be improved.
  • the exhaust gas after having been heat-exchanged in the air heating unit is supplied to between the superheating unit and the evaporation unit, to thereby decrease a difference between the inlet temperature and the outlet temperature of the evaporation unit as compared to that of the conventional art.
  • a heat exchange loss in the evaporation unit can be further reduced.
  • the exhaust heat recovery unit comprises a plurality of heat recovery stages
  • the exhaust gas after having passed through the air heating unit is supplied to between the superheating unit and the evaporation unit provided in the heat recovery stage, to which the exhaust gas having the highest temperature is supplied. Therefore, the exhaust gas temperature at the inlet of the evaporation unit can be dropped, and hence a temperature difference between the inlet and the outlet of the evaporation unit can be reduced as compared to the conventional art, to thereby reduce the heat exchange loss in the evaporation unit. As a result, the heat exchange loss in the exhaust heat recovery unit can be reduced as compared to the conventional art, and hence the combined efficiency can be improved further.
  • the exhaust gas of the gas turbine to be supplied to the exhaust heat recovery unit is branched, and a part of the exhaust gas is supplied to a plurality of air heating units, for heating the combustion air of the gas turbine stepwise.
  • a plurality of heat recovery stages is also provided, where the thermal energy contained in the exhaust gas of the gas turbine is recovered stepwise.
  • the exhaust gas after having been heat-exchanged in the air heating unit is supplied to between the superheating unit and the evaporation unit in the most suitable heat recovery stage, according to the temperature of the exhaust gas. In this manner, the thermal energy contained in the exhaust gas of the gas turbine is recovered stepwise in the heat recovery stage and the air heating unit, and therefore the thermal energy of the exhaust gas can be recovered more efficiently.
  • the exhaust gas since the exhaust gas is branched, and a part thereof is supplied to the air heating unit, and the remaining is supplied to the exhaust heat recovery unit. Therefore, the exhaust gas can be supplied to the exhaust heat recovery unit in an appropriate flow rate. Thereby, a heat exchange loss in the superheating unit provided in the heat recovery stage can be reduced as compared to the conventional art. Further, the exhaust gas after having been heat-exchanged in the air heating unit is supplied to the inlet of the evaporation unit having the most suitable temperature condition according to the temperature thereof, and hence a heat exchange loss in the evaporation unit can be reduced further. By these actions, the combined efficiency can be improved further as compared to the conventional art.
  • the gas turbine combined plant is provided with the flow rate adjusting unit that adjusts the flow rate of the exhaust gas passing through the air heating units in the first stage.
  • the flow rate adjusting unit adjusts the flow rate of the exhaust gas passing through the air heating units in the first stage.
  • the exhaust gas in the most suitable amount can be supplied to the evaporation unit provided in the heat recovery stage, according to the load of the plant and conditions of atmospheric temperature and the like. Therefore, even if the load of the plant and the atmospheric temperature condition and the like change, a heat exchange loss in the evaporation unit can be suppressed low, thereby a drop of the combined efficiency can be minimized. Thus, it is possible to operate the plant while maintaining the high combined efficiency.
  • the exhaust gas branch line is provided with the branch flow adjusting unit that adjusts the branch flow of the exhaust gas to be supplied to the air heating unit is provided in. Therefore, the exhaust gas can be supplied to the exhaust heat recovery unit and the air heating unit, in the most suitable amount according to the load of the plant and conditions of atmospheric temperature and the like. As a result, even if the load of the plant and the atmospheric temperature condition and the like change, a drop of the combined efficiency can be minimized. Thus, it is possible to operate the plant while maintaining the high combined efficiency.
  • the exhaust gas branch line is further provided with the exhaust gas re-combustion unit that supplies fuel to the exhaust gas to reburn the exhaust gas.
  • the temperature of the exhaust gas supplied to the exhaust heat recovery unit can be increased, and hence the temperature of steam superheated by the superheating unit can be increased, thereby increasing the output of the steam turbine to which this steam is supplied. Accordingly, the output of the plant can be also increased.
  • the gas turbine combined plant can be used in such a manner that the output of the plant is increased by the re-combustion unit to thereby deal with the demand, thus enabling extensive plant operation.
  • the re-combustion unit is provided between the branch portion in the exhaust gas branch line and the exhaust heat recovery unit, and hence the length of the exhaust gas branch line that deals with the reburnt high-temperature exhaust gas can be made shorter.
  • any material having a relatively low heat-resistance may be used as a component of the exhaust gas branch line.
  • manufacturing of the exhaust gas branch line becomes relatively easy, and the installation expenses can be also reduced.
  • the gas turbine combined plant of this invention is provided with the control unit that controls the branch flow adjusting unit, so that the flow rate of the exhaust gas to be supplied to the air heating unit is reduced as the temperature of the exhaust gas of the gas turbine increases.
  • the branch flow adjusting unit is controlled based on the exhaust gas temperature of the gas turbine, thereby enabling control with fast response.
  • the gas turbine combined plant of this invention is provided with the control unit that controls the branch flow adjusting unit based on the load of the plant. By having such a configuration, the gas turbine combined plant can be controlled in accordance with the operation program set in advance according to the operation schedule.
  • the method of operating the gas turbine combined plant which does not form a part of this invention comprises reducing the flow rate of the exhaust gas to be supplied to the air heating unit as the temperature of the exhaust gas of the gas turbine increases. Further, the method of operating the gas turbine combined plant of this invention which does not form a part of this invention, comprises reducing the flow rate of the exhaust gas to be supplied to the air heating unit as the load of the gas turbine combined plant increases. In these methods, the flow rate of the exhaust gas to be supplied to the air heating unit is reduced as the exhaust gas temperature of the gas turbine increases, or as the load of the gas turbine combined plant increases. Therefore, even if the temperature of the exhaust gas, the load of the plant, or other factors change, a drop of the combined efficiency can be, suppressed to the minimum. Thus, it is possible to operate the gas turbine combined plant while maintaining the high combined efficiency.

Landscapes

  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Claims (6)

  1. Gasturbinen-Verbundanlage (100, 101, 102, 103, 104), bei welcher vorgesehen sind:
    eine Gasturbine (20);
    eine Abgas-Wärmerückgewinnungseinheit, die Wärmeenergie zurückgewinnt, die in dem Abgas der Gasturbine (20) enthalten ist, durch Bereitstellung mehrerer Wärmerückgewinnungsstufen, die jeweils zumindest eine Überhitzereinheit (40, 41, 42) und eine Verdampfungseinheit (50, 51, 52) aufweisen;
    Lufterwärmungseinheiten in mehreren Stufen, die Verbrennungsluft der Gasturbine (20) durch das Abgas erwärmen;
    eine Abgas-Abzweigleitung, die einen Abzweigabschnitt (78, 88) zum Abzweigen des Abgases aufweisen, und das Abgas der Abwärme-Rückgewinnungseinheit und den Lufterwärmungseinheiten in den mehreren Stufen zuführt;
    eine Abgaszufuhrleitung einer ersten Stufe, die das Abgas nach Erwärmung der Verbrennungsluft der Gasturbine (20) in einer Lufterwärmungseinheit der ersten Stufe zum Ort zwischen der Überhitzereinheit (40, 41, 42) und der Verdampfungseinheit (50, 51, 52) zuführt, die in einer ersten Wärmerückgewinnungsstufe vorgesehen sind; und
    eine Abgasrückführleitung einer nachfolgenden Stufe, die das Abgas, das nach Erwärmung der Verbrennungsluft der Gasturbine (20) in der Lufterwärmungseinheit bzw. die Lufterwärmungseinheiten in einer zweiten Stufe und danach erhalten wird, zum Ort zwischen der Überhitzereinheit (40, 41, 42) und der Verdampfungseinheit (50, 51, 52) zuführt, die in der Wärmerückgewinnungsstufe bzw. dem Wärmerückgewinnungsstufen und hinter einer zweiten Stufe vorgesehen sind.
  2. Gasturbinen-Verbundanlage (100, 101, 102, 103, 104) nach Anspruch 1, welche weiterhin aufweist:
    eine Flussrateneinstelleinheit, die eine Flussrate des Abgases einstellt, das durch zumindest eine Stufe der Lufterwärmungseinheiten in den mehreren Stufen hindurchgeht.
  3. Gasturbinen-Verbundanlage (100, 101, 102, 103, 104) nach Anspruch 1, bei welcher die Abgas-Abzweigleitung mit einer Abzweigfluss-Einstelleinheit (75, 76, 77, 79) versehen ist, die eine Flussrate des Abzweigflusses des Abgases einstellt, welches der Lufterwärmungseinheit zugeführt werden soll.
  4. Gasturbinen-Verbundanlage (100, 101, 102, 103, 104) nach Anspruch 1, bei welcher die Abgas-Abzweigleitung mit einer Abgas-Nachverbrennungseinheit (95) versehen ist, die Kraftstoff dem Abgas zuführt, um das Abgas erneut zu verbrennen.
  5. Gasturbinen-Verbundanlage (100, 101, 102, 103, 104) nach Anspruch 4, bei welcher die Nachverbrennungseinheit (95) zwischen dem Abzweigabschnitt (78, 88) der Abgas-Abzweigleitung und der Abwärme-Rückgewinnungseinheit vorgesehen ist.
  6. Gasturbinen-Verbundanlage (100, 101, 102, 103, 104) nach Anspruch 3, bei welcher die Gasturbine (20) weiterhin eine Steuereinheit (90) aufweist, welche aufweist
    einen Prozessor (91), der ein Signal zum Betätigen der Abzweigfluss-Einstelleinheit (75, 76, 77, 79) aufweist, sodass die Flussrate des Abgases, welches der Lufterwärmungseinheit zugeführt werden soll, verringert wird, wenn die Temperatur des Abgases oder die Belastung der Gasturbine (20) zunimmt; und
    eine Steuerung (93), welche die Abzweigfluss-Einstelleinheit (75, 76, 77, 79) auf Grundlage des Signals von dem Prozessor (91) betätigt, um die Flussrate des der Lufterwärmungseinheit zugeführten Abgases zu ändern.
EP03000550A 2002-01-24 2003-01-10 Kombikraftwerk und Verfahren zu dessen Betrieb Expired - Lifetime EP1331366B1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
EP06008776.4A EP1867843B1 (de) 2002-01-24 2003-01-10 Verfahren zum Betreiben einer kombinierten Gas-Turbogruppe

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
JP2002016067A JP2003214182A (ja) 2002-01-24 2002-01-24 ガスタービンコンバインドプラント、およびその運転方法
JP2002016067 2002-01-24

Related Child Applications (1)

Application Number Title Priority Date Filing Date
EP06008776.4A Division EP1867843B1 (de) 2002-01-24 2003-01-10 Verfahren zum Betreiben einer kombinierten Gas-Turbogruppe

Publications (3)

Publication Number Publication Date
EP1331366A2 EP1331366A2 (de) 2003-07-30
EP1331366A3 EP1331366A3 (de) 2004-05-26
EP1331366B1 true EP1331366B1 (de) 2007-03-07

Family

ID=19191988

Family Applications (2)

Application Number Title Priority Date Filing Date
EP03000550A Expired - Lifetime EP1331366B1 (de) 2002-01-24 2003-01-10 Kombikraftwerk und Verfahren zu dessen Betrieb
EP06008776.4A Expired - Lifetime EP1867843B1 (de) 2002-01-24 2003-01-10 Verfahren zum Betreiben einer kombinierten Gas-Turbogruppe

Family Applications After (1)

Application Number Title Priority Date Filing Date
EP06008776.4A Expired - Lifetime EP1867843B1 (de) 2002-01-24 2003-01-10 Verfahren zum Betreiben einer kombinierten Gas-Turbogruppe

Country Status (6)

Country Link
US (1) US6829898B2 (de)
EP (2) EP1331366B1 (de)
JP (1) JP2003214182A (de)
CN (1) CN1291141C (de)
CA (1) CA2416663C (de)
DE (1) DE60312239T2 (de)

Families Citing this family (26)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE60324368D1 (de) * 2002-08-09 2008-12-11 Hitachi Ltd Kombikraftwerk
US20060196189A1 (en) * 2005-03-04 2006-09-07 Rabbat Michel G Rabbat engine
US20080229749A1 (en) * 2005-03-04 2008-09-25 Michel Gamil Rabbat Plug in rabbat engine
EP1801363A1 (de) * 2005-12-20 2007-06-27 Siemens Aktiengesellschaft Kraftwerksanlage
JP4148281B2 (ja) * 2006-06-19 2008-09-10 ソニー株式会社 モーションキャプチャ装置及びモーションキャプチャ方法、並びにモーションキャプチャプログラム
US20100242429A1 (en) * 2009-03-25 2010-09-30 General Electric Company Split flow regenerative power cycle
DE102009038322A1 (de) * 2009-08-21 2011-02-24 Krones Ag Verfahren und Vorrichtung zur Umwandlung thermischer Energie aus Biomasse in mechanische Arbeit
US20110113786A1 (en) * 2009-11-18 2011-05-19 General Electric Company Combined cycle power plant with integrated organic rankine cycle device
ES2387724B1 (es) * 2010-03-05 2013-08-20 Universidad Nacional De Educación A Distancia Sistema de regeneración parcial en turbinas de gas de ciclos combinados con una o varias fuentes de calor.
DE102010042458A1 (de) * 2010-10-14 2012-04-19 Siemens Aktiengesellschaft Verfahren zum Betreiben einer kombinierten Gas- und Dampfturbinenanlage sowie zur Durchführung des Verfahrens hergerichtete Gas- und Dampfturbinenanlage und entsprechende Regelvorrichtung
US8887481B2 (en) * 2010-12-10 2014-11-18 Alstom Technology Ltd Method for starting a combined cycle power plant
EP2663755A1 (de) * 2011-01-12 2013-11-20 Martin Hadlauer Gas/dampfturbinenanlage für solare anbindung
AT510688B1 (de) * 2011-03-14 2012-06-15 Siemens Vai Metals Tech Gmbh Betriebsverfahren für eine anlage der grundstoffindustrie
US9074494B2 (en) * 2011-10-21 2015-07-07 General Electric Company System and apparatus for controlling temperature in a heat recovery steam generator
ES2775004T3 (es) 2012-03-19 2020-07-23 Stamicarbon B V Acting Under The Name Of Mt Innovation Center Una planta de energía solar térmica y un método para operar una planta de energía solar térmica
US9188028B2 (en) * 2012-10-05 2015-11-17 General Electric Company Gas turbine system with reheat spray control
US9097418B2 (en) * 2013-02-05 2015-08-04 General Electric Company System and method for heat recovery steam generators
US9739478B2 (en) * 2013-02-05 2017-08-22 General Electric Company System and method for heat recovery steam generators
DE102014006909B3 (de) 2014-05-09 2015-07-09 Maschinenwerk Misselhorn Mwm Gmbh Anordnung mit mehreren Wärmeübertragern und Verfahren zum Verdampfen eines Arbeitsmediums
WO2016068837A1 (en) 2014-10-27 2016-05-06 Siemens Aktiengesellschaft Low load turndown for combined cycle power plants
JP6407079B2 (ja) * 2015-03-25 2018-10-17 三菱日立パワーシステムズ株式会社 高湿分空気利用ガスタービンシステム及びその排ガス処理システム
CN107143391A (zh) * 2016-12-16 2017-09-08 华北电力大学 一种新型中间回热燃气轮机联合循环系统
US20180230849A1 (en) * 2016-12-19 2018-08-16 General Electric Company System and Method for Regulating Velocity of Gases in a Turbomachine
KR102058356B1 (ko) * 2018-08-17 2019-12-23 인하대학교 산학협력단 가스터빈 복합 발전시스템
KR102538689B1 (ko) * 2022-02-15 2023-05-30 두산에너빌리티 주식회사 복합 발전 시스템 및 복합 발전 시스템의 구동 방법
CN114810351B (zh) * 2022-04-12 2024-08-13 西安热工研究院有限公司 一种耦合储能系统且压缩流量可调的燃机系统及控制方法

Family Cites Families (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR1352876A (fr) 1962-12-04 1964-02-21 Alsthom Cgee Améliorations aux installations à cycle mixte gaz-vapeur avec chaudière à foyer sous pression
US3422800A (en) 1967-06-19 1969-01-21 Gen Electric Combined gas turbine and waste heat boiler control system
US3675426A (en) * 1970-05-13 1972-07-11 Stein Industrie Method and means for operating a steam gas plant including a gas turbine, a steam turbine with its steam generator at the downstream end
GB2014662A (en) * 1978-02-16 1979-08-30 English Electric Co Ltd Gas Turbine Plant Providing Shaft Power and Heat
US4369624A (en) * 1981-01-02 1983-01-25 Westinghouse Electric Corp. High temperature gas turbine systems
EP0061262A1 (de) * 1981-03-23 1982-09-29 Cpc International Inc. System zur Erzeugung von Energie
DE4029991A1 (de) * 1990-09-21 1992-03-26 Siemens Ag Kombinierte gas- und dampfturbinenanlage
EP0579061A1 (de) * 1992-07-15 1994-01-19 Siemens Aktiengesellschaft Verfahren zum Betreiben einer Gas- und Dampfturbinenanlage sowie danach arbeitende GuD-Anlage
DE19612021C1 (de) 1996-03-27 1997-06-05 Thyssen Stahl Ag Leichtbaurad aus Stahlblech für Fahrzeuge
DE19612921A1 (de) 1996-04-01 1997-10-02 Asea Brown Boveri Kraftwerksanlage und Verfahren zum Betrieb einer Kraftwerksanlage
CA2269731C (en) 1998-04-28 2001-12-11 Mitsubishi Heavy Industries, Ltd. Combined cycle plant
JP2000027662A (ja) 1998-07-10 2000-01-25 Mitsubishi Heavy Ind Ltd 再生式ガスタービンを用いたコンバインドサイクルプラント
DE19943782C5 (de) 1999-09-13 2015-12-17 Siemens Aktiengesellschaft Gas- und Dampfturbinenanlage

Also Published As

Publication number Publication date
EP1867843A1 (de) 2007-12-19
CA2416663A1 (en) 2003-07-24
CA2416663C (en) 2006-11-21
EP1867843B1 (de) 2014-04-02
EP1331366A2 (de) 2003-07-30
CN1291141C (zh) 2006-12-20
EP1331366A3 (de) 2004-05-26
US20030136130A1 (en) 2003-07-24
DE60312239D1 (de) 2007-04-19
JP2003214182A (ja) 2003-07-30
DE60312239T2 (de) 2007-11-22
CN1434197A (zh) 2003-08-06
US6829898B2 (en) 2004-12-14

Similar Documents

Publication Publication Date Title
EP1331366B1 (de) Kombikraftwerk und Verfahren zu dessen Betrieb
US6442924B1 (en) Optimized steam turbine peaking cycles utilizing steam bypass and related process
JP5604074B2 (ja) 給水ポンプサイズを縮小するために燃料ガス加熱器の排水を使用する蒸気温度調節用装置
US6604354B2 (en) Combined cycle power plant
US7509794B2 (en) Waste heat steam generator
JP6749780B2 (ja) 追い焚きガスタービンコンバインドサイクルプラントの改良された温度が比較的低い状態の蒸気タービンを起動する方法
US8387356B2 (en) Method of increasing power output of a combined cycle power plant during select operating periods
JPH07502322A (ja) 多重ボイラプラント内の蒸気システム
JP2004169625A (ja) コージェネレーションプラントおよびその起動方法
JP2915885B1 (ja) ガスタービン複合発電システム
KR101887971B1 (ko) 복합 화력 발전 설비들의 저 부하 턴다운
JPH09303113A (ja) コンバインドサイクル発電プラント
JPH074605A (ja) 複合発電設備
EP3306044A1 (de) Antwortsysteme mit schneller frequenz mit wärmespeicherung für kombikraftwerke
JP3641518B2 (ja) コンバインドサイクルプラントの蒸気温度制御方法及び装置
US20240360775A1 (en) Combined cycle power generation
KR20240159485A (ko) 복합 사이클 발전 시스템
KR20240159486A (ko) 복합 사이클 발전 시스템
JP2001193901A (ja) 排熱回収ボイラ
JPH1193618A (ja) ガスタービン蒸気冷却系統の蒸気圧制御方法
JP4014948B2 (ja) 多軸型コンバインドサイクルプラント及びその制御方法
JPH03115707A (ja) 複合発電プラント
JP2023086015A (ja) 原子力発電プラント
JP2000220412A (ja) 汽力発電設備のリパワリングシステム
JPH0913917A (ja) コンバインドサイクル発電プラントの中圧蒸気量調整方法

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

17P Request for examination filed

Effective date: 20030110

AK Designated contracting states

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IT LI LU MC NL PT SE SI SK TR

AX Request for extension of the european patent

Extension state: AL LT LV MK RO

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IT LI LU MC NL PT SE SI SK TR

AX Request for extension of the european patent

Extension state: AL LT LV MK RO

AKX Designation fees paid

Designated state(s): CH DE FR GB IT LI

GRAP Despatch of communication of intention to grant a patent

Free format text: ORIGINAL CODE: EPIDOSNIGR1

RAP1 Party data changed (applicant data changed or rights of an application transferred)

Owner name: MITSUBISHI HEAVY INDUSTRIES, LTD.

GRAS Grant fee paid

Free format text: ORIGINAL CODE: EPIDOSNIGR3

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): CH DE FR GB IT LI

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: LI

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20070307

Ref country code: CH

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20070307

REG Reference to a national code

Ref country code: GB

Ref legal event code: FG4D

REG Reference to a national code

Ref country code: CH

Ref legal event code: EP

REF Corresponds to:

Ref document number: 60312239

Country of ref document: DE

Date of ref document: 20070419

Kind code of ref document: P

REG Reference to a national code

Ref country code: CH

Ref legal event code: PL

EN Fr: translation not filed
PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed

Effective date: 20071210

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20070307

Ref country code: FR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20071026

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20080110

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: FR

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT

Effective date: 20070307

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20080110

REG Reference to a national code

Ref country code: DE

Ref legal event code: R082

Ref document number: 60312239

Country of ref document: DE

Representative=s name: HOFFMANN - EITLE PATENT- UND RECHTSANWAELTE PA, DE

Ref country code: DE

Ref legal event code: R081

Ref document number: 60312239

Country of ref document: DE

Owner name: MITSUBISHI HITACHI POWER SYSTEMS, LTD., YOKOHA, JP

Free format text: FORMER OWNER: MITSUBISHI HEAVY INDUSTRIES, LTD., TOKYO, JP

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: DE

Payment date: 20211130

Year of fee payment: 20

REG Reference to a national code

Ref country code: DE

Ref legal event code: R071

Ref document number: 60312239

Country of ref document: DE